Riserless completions

ABSTRACT

A downhole barrier system comprising: a wellbore; an upper packer; upper barrier valve; a pressure sensor; a ported sub; a lower packer; a lower pack flow port sliding sleeve; and a lower barrier valve.

CROSS REFERENCE TO RELATED APPLICATIONS

This application claims the benefit of U.S. Provisional Application No.61/888,597, filed Oct. 9, 2013, which is incorporated herein byreference.

BACKGROUND

The present disclosure relates generally to methods of suspending,completing, or working over a well. More specifically, in certainembodiments the present disclosure relates to methods of suspending,completing, or working over a subsea well without the use of a marineriser and blow out preventer system.

In order to provide adequate well control and to satisfy the statutorysafety requirements of many jurisdictions around the world, mostoperating companies adopt the principle of ensuring that at least twoindependently verified barriers are in place at all times during theconstruction or suspension of wells. Conventional methods of suspendingthe well may involve the use of a Mobile Offshore Drilling Unit (MODU)to install completions through a marine riser and subsea blowoutpreventer (BOP) conduit. Typically these conventional methods require anenclosed conduit between the wellhead and the deployment unit tomaintain primary well control and monitor fluid levels in the wellbore.Using these methods may require the MODU on-site throughout thecompletion installation period when it could be better utilized drillingwells or performing other operations.

Other methods of suspending a well are discussed in U.S. Pat. No.7,438,135, the entirety of which is hereby incorporated by reference.Briefly, U.S. Pat. No. 7,438,135 describes method of suspending a wellthat do not require the use of a BOP stack to supplement well control.Disadvantages of such method are that the barrier systems describedtherein may not be suitable for use in open water environments. Inaddition, the methods described therein include intensive high riskwireline operations to install and verify the barriers with no means toisolate the wellbore at the mudline in the event of downhole failure.

It is desirable to develop a method of suspending, completing, orworking over a well that is suitable for open water installation anddoes not require the use of a marine riser and a blowout preventersystem.

SUMMARY

The present disclosure relates generally to methods of suspending,completing, or working over a well. More specifically, in certainembodiments the present disclosure relates to methods of suspending,completing, or working over a subsea well without the use of a marineriser and blow out preventer system

In one embodiment, the present disclosure provides downhole bathersystem comprising: a wellbore; an upper packer; a lower packer; an upperbarrier valve; a lower barrier valve; a pressure sensor; a ported sub;and a lower pack flow port sliding sleeve.

In another embodiment, the present disclosure provides an isolatedwellbore system comprising: a well bore; a downhole bather; a suspensionplug; and a subsea isolation device.

In another embodiment, the present disclosure provides a methodcomprising: providing a well system comprising a well bore and blowoutpreventer; placing a downhole barrier within the wellbore, installing asuspension plug at a top of the well bore; removing the blowoutpreventer, installing an isolation device at the top of the wellbore;removing the suspension plug, installing an upper completion into thewellbore, recovering the subsea isolation device; installing a Christmastree at the top of the wellbore, recovering the suspension plug, andinstalling the Christmas tree cap on the Christmas tree.

BRIEF DESCRIPTION OF THE DRAWINGS

A more complete and thorough understanding of the present embodimentsand advantages thereof may be acquired by referring to the followingdescription taken in conjunction with the accompanying drawings.

FIG. 1 is an illustration of a downhole barrier system in accordancewith certain embodiments of the present disclosure.

FIG. 2 is an illustration of an isolated wellbore system in accordancewith certain embodiments of the present disclosure.

FIGS. 3A-3L are illustrations of a method in accordance with certainembodiments of the present disclosure.

The features and advantages of the present disclosure will be readilyapparent to those skilled in the art. While numerous changes may be madeby those skilled in the art, such changes are within the spirit of thedisclosure.

DETAILED DESCRIPTION

The description that follows includes exemplary apparatuses, methods,techniques, and/or instruction sequences that embody techniques of theinventive subject matter. However, it is understood that the describedembodiments may be practiced without these specific details.

The present disclosure relates generally to methods of suspending,completing, or working over a well. More specifically, in certainembodiments the present disclosure relates to methods of suspending,completing, or working over a well without the use of a marine riser andblow out preventer system.

In certain embodiments, the present disclosure describes methods andsystems that enable upper completions to be installed without requiringthe use of a drilling BOP and/or a marine riser. In certain embodiments,the methods and systems described herein are capable of maintaining apressure control envelop and satisfying the dual barrier requirementsthroughout the suspension, work over, or completion of the well. Incertain embodiments, the present disclosure allows for a riser-lessupper completion installation to be conducted under the protection ofdual barriers with capability to isolate the well should the barrierstatus become degraded. In certain embodiments, the installation of thewell barriers can be safely and efficiently executed during theconstruction lower completion without additional well intervention. Incertain embodiments, the present disclosure offers the ability tomonitor the integrity of the bathers real time throughout any temporarywell suspension and completion installation phases.

In certain embodiments, the present disclosure provides a downholebarrier system comprising a well bore and a downhole bather. Such asystem is illustrated by FIG. 1. Referring now to FIG. 1, FIG. 1illustrates a downhole bather system 100 comprising a wellbore 110 and adownhole bather 120. In certain embodiments, downhole barrier system 100may be a “single trip primary downhole barrier.” As used herein, theterm single trip primary downhole refers to a bather that may bedeployed and verified by a single trip.

In certain embodiments, wellbore 110 may be a wellbore penetrating anytype of subterranean formation. In certain embodiments, wellbore 110 mayservice any type of well. Examples of wells capable of being serviced bywellbore 110 include subsea wells, platform wells, and land wells. Incertain embodiments, the well serviced by wellbore 110 may be an oiland/or gas production well or gas and/or water injection well. Incertain embodiments, wellbore 110 may be lined with a casing 111.

In certain embodiments, downhole bather 120 may comprise upper packer121, lower packer 122, upper barrier valve 123, lower barrier valve 124,ported sub 125, lower pack flow port sliding sleeve 126, and pressuresensor 127.

In certain embodiments, upper packer 121 may comprise any sealing devicecapable of isolating zones in a wellbore. Examples of suitable devicesinclude production packers, straddle packers, gravel pack packers, andexpanding metal-to-metal barrier devices. In certain embodiments, upperpacker 121 may be positioned within wellbore 110 at the top of downholebarrier 120. In certain embodiments, upper packer 121 may isolate a topportion 112 of wellbore 110 from a bottom portion 113 of wellbore 110.In certain embodiments, upper packer 121 may isolate a top portion 112of wellbore 110 from a middle portion 114 of wellbore 110.

In certain embodiments, lower packer 122 may comprise any sealing devicecapable of isolating zones in a wellbore. Examples of suitable devicesinclude production packers, straddle packers, gravel pack packers, andexpanding metal-to-metal barrier devices. In certain embodiments, lowerpacker 122 may be positioned within wellbore 110 below upper packer 121.In certain embodiments, lower packer 122 may isolate a bottom portion113 of wellbore 110 from a top portion 112 of wellbore 110. In certainembodiments, lower packer 122 may isolate a bottom portion 113 ofwellbore 110 from a middle portion 114 of wellbore 110.

In certain embodiments, upper barrier valve 123 may comprise any type ofvalve. Examples of suitable valve types include glass or ceramic discsand flapper or ball mechanisms. In certain embodiments, upper bathervalve 123 may be remotely operated to permit the flow of fluids acrossupper barrier valve 123. In certain embodiments, upper barrier valve 123may be positioned within wellbore 110 below or above upper packer 121and above lower packer 122.

In certain embodiments, lower barrier valve 124 may comprise any type ofvalve. Examples of suitable valve types include glass or ceramic discsand flapper or ball mechanisms. In certain embodiments, lower bathervalve 124 may be remotely operated to permit the flow of fluids acrosslower barrier valve 124. In certain embodiments, lower barrier valve 124may be positioned within wellbore 110 below lower packer 122.

In certain embodiments, ported sub 125 may comprise any tubularcomponent capable of providing pressure communication across the annularspace/void created when installing downhole bather 120. In certainembodiments, ported sub 125 may permit the flow of fluids across portedsub 125. In certain embodiments, ported sub 125 may be positioned withinwellbore 110 below upper barrier valve 123 and above lower barrier valve124.

In certain embodiments, lower pack sliding sleeve 126 may comprise amechanically actuated sleeve capable of isolating fluid circulationports required for sand control circulation. In certain embodiments, thegravel pack sliding sleeve may be closed and become redundant at thecompletion of sand control circulation. In certain embodiments, lowerpack sliding sleeve 126 may be positioned within wellbore 110 belowlower packer 122 and above or below lower barrier valve 124.

In certain embodiments, pressure sensor 127 may comprise any type ofpressure sensing device. In certain embodiments, pressure sensor 127 maybe capable of sensing the pressure within in any portion of thewellbore. In certain embodiments, pressure sensor 127 may be positionedwithin wellbore 110 within middle portion 114 of wellbore 110.

In certain embodiments, downhole barrier system 100 may further comprisesand control / lower completion 130. In certain embodiments, sandcontrol/lower completion 130 may comprise sand screens, tubing,production packers, gravel pack packers, isolation valves, telescopingjoints, circulation mechanisms, hydraulic and electric cablefeed-throughs and connects, pressure and temperature sensors, hydraulicand electric lines, clamps, or wet-mate connectors.

In certain embodiments, downhole barrier system 100 may further comprisean upper completion 140 and a production packer 150. In certainembodiments, upper completion 140 may comprise tubing, productionpacker, gas lift mandrels, telescoping joints, circulation mechanisms,downhole safety valve, chemical injection mandrel, pressure andtemperature gauge mandrel, hydraulic and electric lines, clamps, orwet-mate connectors. In certain embodiments, lower most portion 141 ofupper completion 140 may extend below upper packer 121 of downholebather 120.

In certain embodiments, the present disclosure provides an isolatedwellbore system comprising: a well bore; a downhole bather; a suspensionplug; and a subsea isolation device. Such a system is illustrated inFIG. 2. Referring now to FIG. 2, FIG. 2 illustrates isolated wellboresystem 200 comprising: well bore 210; downhole barrier 220; a suspensionplug 230, and subsea isolation device 240.

In certain embodiments, well bore 210 may comprise any of the featuresdiscussed above with respect to well bore 110. In certain embodiments,wellbore 210 may comprise a casing 211 and a well head 212.

In certain embodiments, downhole bather 220 may comprise any combinationof components that have been configured to provide a primary wellpressure bather. In certain embodiment, each of these components may beintegrated into conventional tools used during the well sandfaceconstruction phase, to provide a single trip bather system with in-builtredundancy. In certain embodiments, each of these components may havedata acquisition functionality that allows confirmation of the integrityof the barrier real-time throughout the lifecycle. In certainembodiments, downhole bather 220 may comprise any combination offeatures discussed above with respect to downhole bather 120. In certainembodiments, downhole bather 220 may be disposed within wellbore 210below well head 212.

In certain embodiments, the suspension plug 230 may comprise anintelligent suspension plug. In certain embodiments, suspension plug 230may be installed within wellbore 210 at wellhead 212. In certainembodiments, suspension plug 230 may seal wellbore 210. In certainembodiments, suspension plug 230 may facilitate the suspension of wellbore 210 allowing for the removal of a drilling BOP. In certainembodiments, suspension plug 230 may utilize existing mechanical bridgeplug technology. In certain embodiments, suspension plug 230 may becapable of monitoring the pressure below and above suspension plug 230when installed. In certain embodiments suspension plug 230 may becapable of transmitting pressure data using acoustic telemetry real-timethrough its lifecycle. In certain embodiments, suspension plug 230 maybe configured to allow through bore access with a workstring in theevent of failure of the primary bather. In certain embodiments, thethrough bore access will be enabled via remote pressure pulseactivation.

In certain embodiments, suspension plug 230 may be recovered during theinstallation of subsea isolation device 240, using specifically designedmechanical-hydraulic function incorporated in the subsea isolationdevice running tool. In certain embodiments, suspension plug 230 may berecovered on the same trip as the installation of subsea isolationdevice 240.

In certain embodiments, subsea well isolation device 240 may comprise aconfiguration of well control rams and preventers, connectors, guidefunnels and circulation ports. In certain embodiments, subsea wellisolation device 240 may comprise the mechanical components necessary toperform wellbore isolation in the event of downhole bather failureduring the installation of an upper completion. In certain embodiments,subsea well isolation device 240 may have the ability to interface witha deepwater drilling BOP system. In certain embodiments, subsea wellisolation device 240 may have the ability to perform bullhead top killoperations, provide orientation for an upper completion tubing hangers,and to pressure test completions post installation. In certainembodiments, subsea well isolation device 240 may be configured tointerface with tubing head spool 241 installed on wellhead 212.

In certain embodiments, subsea well isolation device 240 may be ofmodular design. In certain embodiments, the modular design may allow foran upper portion 242 of subsea well isolation device 240 to beconfigured for well specific completion operations while a lower portion243 of subsea well isolation device 240 provides well isolationfunctionality by facilitating dual shear/sealing capability to complywith the two barrier requirement. In certain embodiments, the modulardesign may allow for lower potion 243 of subsea well isolation device240 to provide an interface platform with two established well barriersfor well recovery using a drilling BOP and marine riser system deployedfrom a conventional MODU. In certain embodiments, upper portion 242 ofsubsea well isolation device 240 may be removed and replaced by adeepwater drilling BOP.

In certain embodiments, subsea well isolation device 240 may be equippedwith data acquisition functionality to indicate well bore pressure andflow. In certain embodiments, subsea well isolation device 240 may servethe functionality of a subsea trip-tank. In certain embodiments, controlsystems on subsea well device 240 may be activated acoustically or withan ROV.

In certain embodiments, the present disclosure provides a methodcomprising: providing a well system comprising a well bore and a blowoutpreventer; placing a downhole barrier within the wellbore, installing asuspension plug at a top of the well bore; removing the blowoutpreventer, installing an isolation device at the top of the wellbore,removing the suspension plug, installing an upper completion into thewellbore, recovering the subsea isolation device, installing a Christmastree, recovering the suspension plug, and installing the Christmas treecap on the Christmas tree. In certain embodiments, the method may alsocomprise installing a tubing hanger plug in the wellbore. In certainembodiments, a lower most portion of the upper completion extends belowa portion of a sand control and barrier system.

Referring now to FIG. 3, FIGS. 3A-3L illustrate the process steps of amethod in accordance with certain embodiments of the present disclosure.FIG. 3A illustrates a well bore 300, casing 305, mud line 310, andblowout preventer 315. Well bore 300 may share any of the featuresdiscussed above with respect to wellbore 110 and well bore 210. Incertain embodiments, casing 305 may line a portion of well bore 300. Incertain embodiments, well bore 300 may be cased and cleaned after theend of a drilling phase.

A downhole bather 320 may then be installed within well bore 300 belowmud line 310, as shown in FIG. 3B. In certain embodiments, downholebather 320 may share any of the features discusses above with respect todownhole barrier 120 and downhole bather 220. In certain embodiments,the downhole barrier 320 may be installed within wellbore 300 in asingle trip.

Once downhole bather 320 is installed within well bore 300, a suspensionplug 325 may be installed at mud line 310, as shown in FIG. 3C. Incertain embodiments, suspension plug 325 may share any of the commonfeatures discussed above with respect to suspension plug 230.

One the suspension plug 235 is installed, the blow out preventer 315 maybe removed, as shown in FIG. 3D.

A subsea isolation device 330 and a tubing head spool 335 may then beinstalled, at the top of the wellbore 300 as shown in FIG. 3E. Incertain embodiments, subsea isolation device 330 may share any of thecommon features discussed above with respect to subsea isolation device240. In certain embodiments tubing head spool 335 may provide a landingpoint for the completion tubing hanger that has not been drilled throughand is configured with a circulation path around the tubing hanger.

The suspension plug 325 may then be recovered as shown in FIG. 3F.

An upper completion 340 may then be installed as shown in FIG. 3G. Incertain embodiments, a lower most portion of the upper completion mayextend below a portion of downhole bather 320. In certain embodiments,upper completion 340 may comprises any of the common features discussedabove with respect to upper completion 140.

The well may then be suspended with a tubing hanger plug 345 at the topof the upper completion 340 as shown in FIG. 3H. In certain embodiments,tubing hanger plug 345 may comprise wireline deployed locking andrelease properties, pressure equalization functionality, and pressuremonitoring capability.

The subsea isolation device 330 may then be recovered as shown in FIG.3I.

A Christmas tree 350 may then be installed as shown in FIG. 3J. Incertain embodiments, Christmas tree 350 may comprise any conventionaltype of subsea Christmas tree. In certain embodiments a dry tree ordebris cap may be installed temporarily prior to the Christmas tree 350installation.

The tubing hanger plug 345 may then be recovered as shown in FIG. 3K.

A Christmas tree cap 355 may then be installed on Christmas tree 350 asshown in FIG. 3L.

While the embodiments are described with reference to variousimplementations and exploitations, it will be understood that theseembodiments are illustrative and that the scope of the inventive subjectmatter is not limited to them. Many variations, modifications, additionsand improvements are possible.

Plural instances may be provided for components, operations and/orstructures described herein as a single instance. In general, structuresand functionality presented as separate components in the exemplaryconfigurations may be implemented as a combined structure or component.Similarly, structures and functionality presented as a single componentmay be implemented as separate components. These and other variations,modifications, additions, and improvements may fall within the scope ofthe inventive subject matter.

1. A downhole barrier system comprising: a wellbore; an upper packer;upper barrier valve; a pressure sensor; a ported sub; a lower packer; alower pack sliding sleeve; and a lower barrier valve.
 2. The downholebarrier system of claim 1, wherein the lower packer is positioned withinthe wellbore below the upper packer.
 3. The downhole barrier system ofclaim 1, wherein the upper barrier valve is positioned within thewellbore above the lower packer.
 4. The downhole barrier system of claim1, wherein the ported sub is positioned within the wellbore below theupper barrier valve and above the lower barrier valve.
 5. The downholebarrier system of claim 1, wherein the lower pack sliding sleeve ispositioned within the wellbore below the lower packer.
 6. The downholebarrier system of claim 1, wherein the pressure sensor is positionedwithin the wellbore below the upper packer and above the lower packer.7. The downhole barrier system of claim 1, further comprising a lowercompletion.
 8. The downhole barrier system of claim 1, furthercomprising an upper completion and a production packer.
 9. The downholebarrier system of claim 8, wherein a lower most portion of the uppercompletion is positioned below the upper packer.
 10. An isolatedwellbore system comprising: a well bore; a downhole barrier positionedwithin the wellbore; a suspension plug installed near the top of thewellbore at a well head; and a subsea isolation device.
 11. The isolatedwellbore system of claim 10, wherein the downhole barrier comprises anupper packer, an upper barrier valve, a pressure sensor, a ported sub, alower packer, a lower pack sliding sleeve, and a lower barrier valve.12. The isolated wellbore system of claim 11, wherein the downholebarrier further comprises and upper completion and a production packer.13. The isolated wellbore system of claim 10, wherein the downholebarrier is positioned within the well bore.
 14. The isolated wellboresystem of claim 10, wherein the suspension plug comprises an intelligentsuspension plug.
 15. The isolated wellbore system of claim 10, whereinthe suspension plug is configured to allow through bore access with aworkstring.
 16. The isolated wellbore system of claim 10, wherein thesubsea isolation device interfaces with a tubing head spool installed onthe wellhead.
 17. The isolated wellbore system of claim 1, wherein thesubsea isolation device is capable of interfacing with a drilling BOPsystem.
 18. A method comprising: providing a well system comprising awell bore, a casing, and a blowout preventer; placing a barrier withinthe wellbore; installing a suspension plug at a top of the well bore;removing the blowout preventer; installing an isolation device at thetop of the wellbore; removing the suspension plug; installing an uppercompletion; installing a tubing hanger plug; recovering the subseaisolation device; installing a Christmas tree; recovering the suspensionplug; and installing the Christmas tree cap.
 19. The method of claim 17,wherein the barrier comprises an upper packer, an upper barrier valve, apressure sensor, a ported sub, a lower packer, a lower pack slidingsleeve, and a lower barrier valve.
 20. The method of claim 3, furthercomprises installing a tubing hanger plug.